EP2103339B1 - Abgasbehandlungsverfahren und vorrichtung - Google Patents

Abgasbehandlungsverfahren und vorrichtung Download PDF

Info

Publication number
EP2103339B1
EP2103339B1 EP07859994.1A EP07859994A EP2103339B1 EP 2103339 B1 EP2103339 B1 EP 2103339B1 EP 07859994 A EP07859994 A EP 07859994A EP 2103339 B1 EP2103339 B1 EP 2103339B1
Authority
EP
European Patent Office
Prior art keywords
exhaust gas
heat recovery
recovery unit
exit
heating medium
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
EP07859994.1A
Other languages
English (en)
French (fr)
Other versions
EP2103339A4 (de
EP2103339A1 (de
EP2103339B8 (de
Inventor
Kazuki Kobayashi
Hirofumi Kikkawa
Hiroshi Ishizaka
Hiroshi Takezaki
Hiroyuki Nosaka
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Mitsubishi Power Ltd
Original Assignee
Mitsubishi Hitachi Power Systems Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Mitsubishi Hitachi Power Systems Ltd filed Critical Mitsubishi Hitachi Power Systems Ltd
Priority to PL07859994T priority Critical patent/PL2103339T3/pl
Publication of EP2103339A1 publication Critical patent/EP2103339A1/de
Publication of EP2103339A4 publication Critical patent/EP2103339A4/de
Publication of EP2103339B1 publication Critical patent/EP2103339B1/de
Application granted granted Critical
Publication of EP2103339B8 publication Critical patent/EP2103339B8/de
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J15/00—Arrangements of devices for treating smoke or fumes
    • F23J15/003—Arrangements of devices for treating smoke or fumes for supplying chemicals to fumes, e.g. using injection devices
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/02—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography
    • B01D53/06—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography with moving adsorbents, e.g. rotating beds
    • B01D53/10—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography with moving adsorbents, e.g. rotating beds with dispersed adsorbents
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/48—Sulfur compounds
    • B01D53/50—Sulfur oxides
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/64—Heavy metals or compounds thereof, e.g. mercury
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
    • B01D53/86—Catalytic processes
    • B01D53/8621—Removing nitrogen compounds
    • B01D53/8625—Nitrogen oxides
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J15/00—Arrangements of devices for treating smoke or fumes
    • F23J15/006—Layout of treatment plant
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J15/00—Arrangements of devices for treating smoke or fumes
    • F23J15/02—Arrangements of devices for treating smoke or fumes of purifiers, e.g. for removing noxious material
    • F23J15/022—Arrangements of devices for treating smoke or fumes of purifiers, e.g. for removing noxious material for removing solid particulate material from the gasflow
    • F23J15/025—Arrangements of devices for treating smoke or fumes of purifiers, e.g. for removing noxious material for removing solid particulate material from the gasflow using filters
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/60—Heavy metals or heavy metal compounds
    • B01D2257/602—Mercury or mercury compounds
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2215/00—Preventing emissions
    • F23J2215/60—Heavy metals; Compounds thereof
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2217/00—Intercepting solids
    • F23J2217/10—Intercepting solids by filters
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2219/00—Treatment devices
    • F23J2219/40—Sorption with wet devices, e.g. scrubbers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2219/00—Treatment devices
    • F23J2219/60—Sorption with dry devices, e.g. beds
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2219/00—Treatment devices
    • F23J2219/70—Condensing contaminants with coolers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2900/00—Special arrangements for conducting or purifying combustion fumes; Treatment of fumes or ashes
    • F23J2900/15081—Reheating of flue gases

Definitions

  • the present invention relates to an exhaust gas treating method and apparatus and particularly relates to an apparatus and a method, which are for reducing trace component concentrations in an exhaust gas discharged from a chimney and with which trace component removal performance in a dry precipitator is improved to remove trace heavy metal components in the exhaust gas.
  • Mercury and other heavy metals are contained in addition to nitrogen oxides and sulfur oxides in an exhaust gas discharged from a thermal power plant boiler, etc., which is a combustion apparatus that uses coal or other fossil fuel.
  • the nitrogen oxides are removed by NOx removal equipment and the sulfur oxides are removed by a desulfurizer, mercury, selenium, cadmium, chromium, lead, zinc, and other heavy metals cannot be removed by the NOx removal equipment or desulfurizer and cannot be trapped completely by a precipitator for removing soot/dust in the exhaust gas. Because these heavy metals are high in toxicity, emission restrictions thereof have recently become stricter. Methods for removing heavy metals contained in the exhaust gas, particularly mercury, which is high in toxicity, are being examined.
  • Fig. 11 illustrates one such method and shows an exhaust gas treating system applied to remove mercury in an exhaust gas from a waste incinerator or other combustion furnace 1.
  • the exhaust gas from the combustion furnace 1 is first treated by NOx removal equipment 2 to remove nitrogen oxides, and combustion air to be used in the combustion furnace 1 is then heated by the exhaust gas in an air preheater 3. Soot/dust in the exhaust gas discharged from the air preheater 3 are then trapped by a precipitator 4, the exhaust gas discharged from the precipitator 4 is guided by an induction fan 5 to a wet flue gas desulfurizer 6 to remove sulfur oxides in the exhaust gas, and the exhaust gas is discharged by a boost-up fan 7 into air from a chimney 8.
  • a measurement unit 9 for measuring concentrations of the sulfur oxides, nitrogen oxides, heavy metals (Hg), etc., in the exhaust gas is disposed at an upstream side of the chimney 8 to monitor concentrations of these components in the exhaust gas.
  • the exhaust gas treating system of Fig. 11 is characterized in that a mercury adsorbent from a mercury adsorbent supply unit 16 is added into the exhaust gas at an entrance of the precipitator 4, and with this exhaust gas treating system, the exhaust gas at the entrance of the precipitator 4 is in a temperature range (150 to 240°C) in which a mercury adsorption performance of activated carbon, etc., is highest and the activated carbon, etc., to which mercury has become adsorbed, is recovered by the precipitator 4 (see, for example, Non-Patent Document 1, etc.).
  • Fig. 12 shows an exhaust gas treating system applied to removing mercury in an exhaust gas from a thermal power plant boiler, and with this system, heavy metal concentrations in the exhaust gas that is discharged to the atmosphere are adjusted to be within predetermined ranges by lowering an exhaust gas temperature.
  • the exhaust gas from the boiler or other combustion apparatus 1 is supplied to the NOx removal equipment 2 to be removed of the nitrogen oxides and is thereafter used for heating the combustion air in the air preheater 3.
  • a heating medium in a heat recovery unit 11 is then heated by the exhaust gas discharged from the air preheater 3, the soot/dust in the exhaust gas that has been lowered in temperature and is discharged from the heat recovery unit 11 are trapped efficiently by the precipitator 4, and the exhaust gas discharged from the precipitator 4 is guided by the induction fan 5 to the wet flue gas desulfurizer 6 to be desulfurized.
  • the exhaust gas discharged from the wet flue gas desulfurizer 6 is reheated by a reheater 13 using the heating medium that is circulatingly supplied from the heat recovery unit 11 via heating medium circulating ducts 15-1 and 15-2, and is discharged by the boost-up fan 7 into air from the chimney 8 (Patent Document 1).
  • the measurement unit 9 for measuring the concentrations of the sulfur oxides, nitrogen oxides, heavy metals, etc., in the exhaust gas before discharge from the chimney 8 is also disposed in the system shown in Fig. 12 to monitor the concentrations of these components in the exhaust gas.
  • the exhaust gas treating system shown in Fig. 12 makes use of the fact that the heavy metals in the exhaust gas become attached more readily to solid surfaces of ash particles, etc., the lower the exhaust gas temperature, and the heavy metals in the ash particles can be recovered by an appropriate method or a treatment for preventing elution from the ash particles can be applied.
  • Patent Document 1 it is disclosed that a heavy metal concentration in the exhaust gas can be suppressed by a method of measuring the concentration of the heavy metal (Hg) in the exhaust gas discharged from the wet flue gas desulfurizer 6 in the exhaust gas treating system shown in Fig.
  • Patent Document 2 JP 2000-325747 A (Patent Document 2) said that Hg in a combustion gas of the coal (a chlorine compound preliminarily introduce in the coal at boiler 2) is removed and collected as soot dust at a dust collector 7. Gas temperature at an entrance of the dust collector 7 is preferably 150 °C or less to collect the dust. Patent Document 2 shows that when coal is burned by the addition of chlorine compounds in advance, Hg in the dust can be caught at a dust collector 7.
  • JP 2000-015057 A shows that an exhaust gas treatment apparatus is provided with a waste heat recovery system 2 for recovering heat from an exhaust gas of an incinerator 1, an adsorption reactor 4 packed with active carbon for adsorbing dioxin from the incinerator 1 and connected to a downstream side of the waste heat recovery system 2 and a regenerator 5 for heating and regenerating the dioxin adsorbent (active carbon) for recycling to the adsorption reactor 4 and removing gas (SO 2 for dioxin inhibitor (reaction retardant) for supplying to the incinerator 1 by supply line L10.
  • a waste heat recovery system 2 for recovering heat from an exhaust gas of an incinerator 1
  • an adsorption reactor 4 packed with active carbon for adsorbing dioxin from the incinerator 1 and connected to a downstream side of the waste heat recovery system 2 and a regenerator 5 for heating and regenerating the dioxin adsorbent (active carbon) for recycling to the adsorption reactor 4 and removing gas (SO
  • JP 2004-154683 A shows to provide a method of economically removing sulfuric acid (SO 3 ) mist from the exhaust gas of boiler.
  • the exhaust gas treatment equipment is provided with an air pre-heating unit 3 for heating combustion air by exhaust gas discharged from a boiler 1; a heat recovery unit 11 for heating a heating medium by the exhaust gas; a wet type desulfurization device 6 for the exhaust gas; a re-heating unit 13 for heating the exhaust gas by the heating medium; and a heating medium circulation line 15 for circulating the heating medium between the re-heating unit 13 and the heat recovery unit 11.
  • the dew point of SO 3 mist in the exhaust gas is between the temperature of the exhaust gas at an entrance of the heat recovery unit 11 and at a discharge port of a dust-collector 4 and is adjusted such that it becomes higher than the temperature of the exhaust gas at the discharge port of the dust-collector 4 by 30°C or more.
  • Smoke dust by heavy oil does not react with SO 3
  • the quantity of the dust by heavy oil is previously known and the quantity of SO 3 reacts with the concentration of coal ash is known.
  • the concentration of coal ash is calculated from the mixing ratio from the detected value of the concentration of smoke dust and the quantity of SO 3 reacts with the concentration of coal ash is known.
  • the dew point of SO 3 based on the concentration of SO 3 in consideration of the reduced content is calculated to control the circulated quantity of a heat transfer medium to the recuperator 6 from a waste gas reheating heat exchanger 10 from heat transfer medium piping 25.
  • Patent Document 6 shows that an exhaust gas processing system capable of economically removing heavy metal, comprising an air preheater 3, a heat recovery unit 11 for heating a heat medium by exhaust gas discharged from the air preheater 3, a dust collector 4 for collecting soot and dust in exhaust gas from the heat recovery unit 11, a wet-type desulfurization apparatus 6 and a reheater 13, and a heat medium circulation pipe passage 15 for circulating the heating medium between the reheater 13 and the heat recovery unit 11, wherein the heating medium circulation pipe 15 is provided with temperature control means which measures a heavy metal concentration in exhaust gas from any one or more of the dust collector 4, the apparatus 6 and the reheater 13, and adjust the temperature of exhaust gas at an outlet of the heat recovery unit 11 such that the measured value falls within a predetermined range.
  • Non-Patent Document 1 Tatsuhiro Fujii and six others, "Development and Practical Application of a Comprehensive Exhaust Gas Treating System for Bag Filter Type Municipal Waste Incinerator," Hitachi Zosen Technical Review, Hitachi Shipbuilding Corporation, June, 1992, Vol. 53, No. 2, p. 23-30 .
  • a object of the present invention is to provide an exhaust gas treating method and apparatus that effectively removes heavy metals in an exhaust gas even in a case where coal that contains a high amount of sulfur is used as a fuel.
  • the object of the present invention can be achieved by the following.
  • a first aspect of the present invention provides an exhaust gas treating method comprising the steps of: preheating a combustion air of a combustion apparatus (1) by an exhaust gas discharged from the combustion apparatus (1); recovering heat from the exhaust gas by a heat recovery unit (11) after the air preheating; and recovering soot/dust in the exhaust gas at an exit of the heat recovery unit (11) by a dry precipitator (4); characterized in that after adjusting an exhaust gas temperature at the exit of the heat recovery unit (11) to not more than a dew point temperature of sulfur trioxide, a heavy metal adsorbent is supplied into the exhaust gas at an entrance of the dry precipitator (4) or into an intermediate position within the dry precipitator (4), and wherein the heat of the exhausted gas is recovered in a heating medium in the heat recovery unit (11), the heating medium is circulatingly supplied to a reheater (13), disposed for heating the desulfurized exhaust gas by the heating medium supplied from the heat recovery unit (11), or to a cooler (25), disposed for cooling the heating medium supplied from the
  • a second aspect of the present invention provides the exhaust gas treating method according to the first aspect where a nitrogen oxide in the exhaust gas is denitrated by a denitration catalyst before the air preheating and a sulfur oxide in the exhaust gas is desulfurized at the exit of the dry precipitator (4).
  • a third aspect of the present invention provides the exhaust gas treating method according to first aspect wherein the heavy metal adsorbent is supplied into the exhaust gas at the entrance of the dry precipitator (4) 0.1 seconds after adjusting the exhaust gas temperature at the exit of the heat recovery unit (11) to not more than the dew point temperature of sulfur trioxide.
  • a fourth aspect of the present invention provides the exhaust gas treating method according to the first aspect wherein an alkali is sprayed into the exhaust gas at an entrance or exit of the heat recovery unit (11) and the heavy metal adsorbent is supplied after adjusting the exhaust gas temperature at the exit of the heat recovery unit to not more than the dew point temperature of sulfur trioxide.
  • a fifth aspect of the present invention provides the exhaust gas treating method according to the first aspect wherein at least one among a sulfur trioxide concentration, a chlorine concentration, and a heavy metal concentration in the exhaust gas at the exit of the dry precipitator (4) is measured and an amount of the alkali that is in accordance with the measured concentration is supplied into the exhaust gas at the entrance of the heat recovery unit (11) or the exit of the heat recovery unit (11).
  • a sixth aspect of the present invention provides the exhaust gas treating apparatus comprising: an air preheater (3), preheating a combustion air of the combustion apparatus (1) by an exhaust gas discharged from the combustion apparatus (1); a heat recovery unit (11) recovering heat from the exhaust gas at an exit of the air preheater (3); and a dry precipitator (4), recovering soot/dust in the exhaust gas at an exit of the heat recovery unit (11), which are successively disposed from an upstream side to a downstream side of an exhaust gas duct of a combustion apparatus (1); which is characterized in further comprising; a controller (24), controlling an exhaust gas temperature at the exit of the heat recovery unit (11) to not more than a dew point temperature of sulfur trioxide; and a heavy metal adsorbent supply unit (16), supplying a heavy metal adsorbent into the exhaust gas at an entrance of the dry precipitator (4) or into an intermediate position within the dry precipitator (4), and wherein the heat recovery unit (11) comprises a set of heat exchanger tubes that recover the heat of
  • An eighth aspect of the present invention provides the exhaust gas treating apparatus according to sixth aspect, further comprising : an alkali supply unit 17, supplying an alkali into the exhaust gas at the entrance of the heat recovery unit 11 or the exit of the heat recovery unit 11.
  • NOx removal equipment (2) in turn comprising a denitration catalyst that denitrates the exhaust gas at an entrance of the air preheater (3); and a desulfurizer (6), desulfurizing the exhaust gas at the exit of the dry precipitator (4).
  • a ninth aspect of the present invention provides the exhaust gas treating apparatus, which is characterized in further comprising; a heavy metal adsorbent supply unit (16), supplying a heavy metal adsorbent into the exhaust gas at an entrance of the dry precipitator (4) or into an intermediate position within the dry precipitator (4), and an alkali supply unit (17), supplying an alkali into the exhaust gas at the entrance of the heat recovery unit (11) or the exit of the heat recovery unit (11) and a measurement unit (21-23), measuring at least one among a sulfur trioxide concentration, a chlorine concentration, and a heavy metal concentration in the exhaust gas at the exit of the dry precipitator (4); and an adjusting unit (10), adjusting, by the controller (24), an amount of the alkali supplied from the alkali supply unit (17), into the exhaust gas at the entrance of the heat recovery unit (11) or the exit of the heat recovery unit (11); in accordance with the measurement values of the measurement unit (21-23).
  • a configuration where the set of heat exchanger tubes, through which the heating medium that recovers the heat of the exhaust gas flows, is disposed to perform heat exchange with a heat releasing equipment disposed separately from the above-described exhaust gas system, or a configuration, where the set of heat exchanger tubes, through which the heating medium flows, is not disposed and cooling water is sprayed directly inside the heat recovery unit, etc., is used.
  • any one of the various types of desulfurizers such as a wet flue gas desulfurizer, a dry flue gas desulfurizer, etc., may be used.
  • a portion of sulfur dioxide (SO 2 ) in an exhaust gas that is generated when a fossil fuel is combusted reacts with oxygen in the exhaust gas due to a catalytic action of a denitration catalyst, etc., and is converted to sulfur trioxide (SO 3 ).
  • SO 2 sulfur dioxide
  • SO 3 sulfur trioxide
  • a concentration of sulfur dioxide (SO 2 ) in an exhaust gas discharged from a coal burning boiler, etc. is generally approximately 300 to 3000ppm and thus a concentration of sulfur trioxide (SO 3 ) in the exhaust gas is approximately 3 to 90ppm, with a high sulfur content coal, in which a sulfur concentration in coal exceeds 4%, the concentration of sulfur trioxide (SO 3 ) may exceed 100ppm.
  • the present inventors presumed the sulfur oxides in the exhaust gas to be an impediment against the removal of heavy metals.
  • a relationship between the generated amounts of the sulfur oxides and a heavy metal adsorption performance of activated carbon, which is a heavy metal adsorbent, etc. the following facts were found.
  • Fig. 5 shows a relationship between the temperature of an exhaust gas in a dry precipitator and the concentration of sulfur trioxide (entrance SO 3 ) in the exhaust gas for cases of combusting various types of coal (various types of coal differing in sulfur content), and here, a dew point of sulfur trioxide (SO 3 ) is determined by a water concentration and the sulfur trioxide (SO 3 ) concentration in the exhaust gas, being 147°C when the water concentration in the exhaust gas is 10% and the sulfur trioxide (SO 3 ) concentration is 50ppm and being approximately 162°C when the water concentration in the exhaust gas is 15% and the sulfur trioxide (SO 3 ) concentration is 100ppm.
  • the sulfur trioxide (SO 3 ) concentration in the exhaust gas decreases significantly when the exhaust gas temperature decreases . This is because when the exhaust gas temperature decreases, the sulfur trioxide (SO 3 ) reacts with the water in the exhaust gas and condenses as sulfuric acid mist (H 2 SO 4 ) so that hardly any sulfur trioxide (SO 3 ) remains in the exhaust gas.
  • the dew point of sulfur trioxide (SO 3 ) depends on the amounts of the sulfur trioxide (SO 3 ) and water, and whereas the dew point of sulfur trioxide (SO 3 ) in a case of an exhaust gas of a boiler in which coal with a normal sulfur content (coal with a sulfur concentration of not more than 3%) is combusted is 120 to 160°C, the dew point of sulfur trioxide (SO 3 ) in a case of an exhaust gas of a boiler in which coal with a high sulfur content (coal with a sulfur concentration exceeding 3%) is combusted may be not less than 160°C.
  • the sulfur trioxide (SO 3 ) in the exhaust gas can be condensed and converted to sulfuric acid mist (H 2 SO 4 ).
  • the present inventors considered that when mercury and other heavy metals coexist with sulfur trioxide (SO 3 ) in an exhaust gas, the sulfur trioxide (SO 3 ) becomes adsorbed with priority over mercury and other heavy metals to active sites of non-combusted portions in the ash, etc., thereby impeding the adsorption of mercury and other heavy metals to the active sites and significantly lowering the concentrations of mercury and other heavy metals in a recovered ash.
  • SO 3 sulfur trioxide
  • Fig. 6 shows mercury concentrations in ash recovered in a dry precipitator 4 in an exhaust gas treating system shown in Fig. 1 when the temperature of an exhaust gas entering into the precipitator 4 is changed by a heat recovery unit 11 at a front stage of the precipitator 4.
  • the mercury adsorbent of an amount of 0.5% with respect to ash was sprayed at an exit (rear stage) of the heat recovery unit 11.
  • the dry precipitator 4 is set to a temperature of 160 °C, even when the mercury adsorbent is sprayed, the mercury concentration in the ash recovered by the dry precipitator 4 hardly differs from the case of not spraying the mercury adsorbent. This is considered to be because a large amount of sulfur trioxide (SO 3 ) exists in the exhaust gas and the sulfuric mist thus becomes adsorbed to the active sites of the mercury adsorbent, making it difficult for the mercury to become adsorbed.
  • SO 3 sulfur trioxide
  • Fig. 7 shows a relationship between a retention time after the exhaust gas temperature reaches the dew point of sulfur trioxide (SO 3 ) and the sulfurtrioxide (SO 3 ) removal performance, and to remove sulfur trioxide (SO 3 ) efficiently, it is preferable to provide a retention time of not less than 0.1 seconds for completion of the adsorption of sulfur trioxide (SO 3 ) to the ash before adding the mercury adsorbent.
  • the effect of the mercury adsorbent can be improved further by decreasing the sulfur trioxide (SO 3 ) remaining at the rear stage of the heat recovery unit 11 ( Fig. 1 , etc.) by spraying an alkali, such as sodium carbonate (Na 2 CO 3 ), into the exhaust gas at the entrance (front stage) or the exit (rear stage) of the heat recovery unit 11 to neutralizingly remove sulfur trioxide (SO 3 ) (SO 3 + Na 2 CO 3 ⁇ Na 2 SO 4 +CO 2 ).
  • an alkali such as sodium carbonate (Na 2 CO 3
  • alkali used in the present invention sodium carbonate, sodium bicarbonate, potassium carbonate, potassium bicarbonate, or calcium carbonate, etc., each of which is alkaline, is used.
  • Fig. 8 shows a relationship of a concentration of an acidic substance (SO 3 , Cl 2 , or HCl) in the exhaust gas and an amount of alkali added to the exhaust gas.
  • a control range in Fig. 8 is an appropriate range of the alkali supplying amount for improving the Hg removal performance.
  • the hydrogen chloride concentration can be detected by a commercially available HCl meter, the mercury concentration can be detected by a commercially available continuous mercury monitor, and the sulfur trioxide (SO 3 ) concentration can be detected by a commercially available sulfur trioxide (SO 3 ) concentration meter.
  • Fig. 9 shows a variation of the mercury concentration in the exhaust gas when the alkali (Na 2 CO 3 ) is added at molar equivalents with respect to the sulfur trioxide (SO 3 ) in the exhaust gas.
  • the mercury concentration in the exhaust gas was minimized when the alkali (Na 2 CO 3 ) was added at an amount of 1 molar equivalent with respect to the sulfur trioxide (SO 3 ) .
  • the mercury adsorbent is sprayed at an intermediate position in the interior of the dry precipitator (DEP) 4, because ash, to which mercury is hardly attached, is recovered at a front stage portion of the dry precipitator 4, the adsorbent and ash, to which mercury has become adsorbed, is recovered at a rear stage portion, and the sulfur content of the ash at the front stage portion of the dry precipitator 4 can be removed by rinsing with water, the recovered ash after sulfur content removal can be put to effective use as ash that does not contain mercury.
  • soot/dust recovery ash which exhibits adsorption performance and to which the sulfuric acid mist has not become attached
  • silica gel, alumina, zeolite, synthetic zeolite, or a metal oxide or resin based adsorbent, etc. may be used as the mercury adsorbent.
  • mercury and other heavy metals in the exhaust gas can be reduced in the case of combusting high sulfur content coal.
  • the exhaust gas temperature can be adjusted readily within the same exhaust gas system because the exhaust gas temperature at the exit of the heat recovery unit 11 is adjusted according to at least one among the amount of circulation of the heating medium between the heat recovery unit 11 and the reheater 13, connected by the circulation line 15 through which the heating medium flows, or the cooler (heater for water) 25, cooling the heating medium supplied from the heat recovery unit 11, the heating medium heating amount, and the heating medium cooling amount.
  • mercury and other heavy metals in the exhaust gas scan be reduced by almost 99% with respect to the concentration at the boiler exit.
  • the adsorption of sulfur trioxide (SO 3 ) to the ash can be completed before addition of the mercury adsorbent and the concentrations of mercury and other heavy metals in the exhaust gas can be reduced further.
  • waste of the added alkali amount is eliminated and a contribution is made to prevention of equipment degradation because at least one among the sulfur trioxide (SO 3 ) concentration, the chlorine (Cl 2 or HCl) concentration, and the heavy metal concentration in the exhaust gas at the exit of the dry precipitator 4 is measured and an amount of alkali that is in accordance with the measured concentration is added into the exhaust gas.
  • SO 3 sulfur trioxide
  • Cl 2 or HCl chlorine
  • the heavy metal concentration in the exhaust gas at the exit of the dry precipitator 4 is measured and an amount of alkali that is in accordance with the measured concentration is added into the exhaust gas.
  • Fig. 1 is a block diagram of an exhaust gas treating system of an embodiment. Concentrations of exhaust gas components discharged from a boiler used in the embodiment according to the present invention are : a soot/dust concentration of 20g/m 3 N; a NOx concentration of 200ppm; a SOx concentration of 4000ppm; and an Hg concentration of 10 ⁇ g/ m 3 N.
  • an exhaust gas discharged from the boiler 1 is introduced into NOx removal equipment 2, and, after elimination of nitrogen oxides in the exhaust gas to not more than 20ppm by a denitration catalyst, etc., inside the NOx removal equipment 2, the exhaust gas is introduced into an air preheater 3.
  • the exhaust gas introduced into the air preheater 3 undergoes heat exchange with a combustion air that is supplied to the boiler 1 and, upon being cooled, for example, to 120 to 170°C, the exhaust gas is introduced into a heat recovery unit 11.
  • Heat of the exhaust gas introduced into the heat recovery unit 11 is recovered by heat exchange with a heating medium that flows through a heat exchanger tube, and the exhaust gas is preferably cooled to not more than a dew point of sulfur trioxide (SO 3 ), that is, for example, to 75 to 110°C.
  • SO 3 sulfur trioxide
  • the sulfur trioxide (SO 3 ) in the exhaust gas becomes adsorbed as sulfuric acid mist to ash and is guided to a dry electrostatic precipitator 4 where it is trapped along with soot/dust.
  • a mercury adsorbent made up of powder activated carbon of an average particle diameter of 15 ⁇ m, is added at a front stage of the electrostatic precipitator 4 at an amount of approximately 50mg/m 3 N from a mercury adsorbent supply unit 16, adsorbs mercury, and is removed by the electrostatic precipitator 4.
  • the exhaust gas that has passed through the electrostatic precipitator 4 is raised in pressure and introduced by an induction fan 5 into a wet desulfurizer 6, which is based on a spray type limestone-gypsum method and is one example of a desulfurizer, and SOx in the exhaust gas is removed to not more than 40ppm by gas-liquid contact.
  • the exhaust gas which has been cooled to a saturation gas temperature in the wet desulfurizer 6, is raised in temperature by a reheater 13 and then discharged from a chimney 8 via a desulfurization fan 7.
  • the reheater 13 is a heat exchanger having a heat exchanger tube through which the heating medium flows, and the exhaust gas is raised in temperature, for example, to 90 to 110°C by heat exchange with the heating medium that flows through the heat exchanger tube.
  • the heat exchanger tubes of the heat recovery unit 11 and the reheater 13 are made to communicate by the heating medium circulating ducts 15-1 and 15-2, and the heating medium is made to circulate between the heat recovery unit 11 and the reheater 13 by a pump 10.
  • An exhaust gas thermometer 20 is disposed to measure an exit exhaust gas temperature of the heat recovery unit 11. Also, a controller 24 is installed to determine an amount of the heating medium circulated by the heating mediumpump 10, etc., to control the exit exhaust gas temperature of the heat recovery unit 11 based on a measurement result of the exhaust gas thermometer 20.
  • control of the exhaust gas temperature by the heating medium flow rate may also be performed by using one or more among a means that cools the heating medium, a means that heats the heating medium, and a means of adjusting the heating medium flow rate in a bypass tube installed so as to shortcut an entrance and an exit of the heating medium duct passing through the heat recovery unit 11.
  • the control of the exhaust gas temperature by the heating medium flow rate is performed in common in other embodiments as well.
  • the exit exhaust gas temperature of the heat recovery unit 11 may also be adjusted, without using the reheater 13, by exchange of heat with a component outside the exhaust gas system shown in Fig. 1 .
  • the exhaust gas temperature at the exit of the heat recovery unit 11 is controlled to not more than the temperature at which sulfur trioxide (SO 3 ) condenses to increase an efficiency of removal of the sulfuric acid mist in the exhaust gas, and further, the mercury adsorbent from the mercury adsorbent supply unit 16 is added into the exhaust gas in which sulfur trioxide (SO 3 ) hardly remains to enable an efficiency of removal of mercury in the exhaust gas to be increased.
  • the controller 24 performs a control of supplying the mercury adsorbent from the mercury adsorbent supply unit 16 into the exhaust gas.
  • the sulfur trioxide (SO 3 ) concentration in the exhaust gas is not more than 50ppm in a case where a sulfur content of coal used in a coal-burning boiler is not more than 2%, when coal of a high sulfur content of not less than 4% is combusted, the sulfur trioxide (SO 3 ) concentration exceeds 100pm. It is clear that when the mercury adsorbent (activated carbon, etc.) is used in such an exhaust gas that contains a comparatively large amount of sulfur trioxide (SO 3 ) , the mercury in the exhaust gas flows to a downstream side without becoming adsorbed by the adsorbent.
  • the mercury concentration in the exhaust gas can be confirmed by monitoring by a continuous mercury monitor incorporated in a measurement unit 9 disposed in front of the chimney 8, and the NOx and SOx in the exhaust gas can be confirmed to respectively meet regulation values by monitoring by respective monitors incorporated in the measurement unit 9.
  • the continuous mercury monitor incorporated in the measurement unit 9 and by monitoring the NOx and SOx in the exhaust gas by respective monitors incorporated in the measurement unit 9 it could be confirmed that the respective concentrations meet the regulation values.
  • plant operation is discontinued if the regulation values are deviated from, deviations from the regulation values do not occur with the present embodiment.
  • the sulfuric acid mist is neutralized and rendered harmless by the coal ash, which is contained in the exhaust gas and is high in alkalinity, corrosion of equipment can be prevented and it was possible to prevent corrosion of the apparatus even at one year from a start of operation.
  • An embodiment shown in Fig. 2 is an exhaust gas treating system with which a configuration for adding an alkali is added to the exhaust gas treating system shown in Fig. 1 and furthermore with which at least one among an SO 3 concentration meter 21, measuring the SO 3 concentration in the exit exhaust gas of the dry electrostatic precipitator 4, a hydrogen chloride concentration meter 22, measuring a hydrogen chloride concentration, and a heavy metal concentration meter 23, measuring a heavy metal concentration, is disposed.
  • the boiler 1, the NOx removal equipment 2, the air preheater 3, the heat recovery unit 11, the induction fan 5, the wet desulfurizer 6, the reheater 13, the desulfurization fan 7, the measurement unit 9, the chimney 8, the pump 10, the heating medium circulating ducts 15-1 and 15-2, the mercury adsorbent supply unit 16, the thermometer 20 at the heat recovery unit exit, and the controller 24 are the same as those of Embodiment 1 and description thereof shall be omitted.
  • the exit exhaust gas temperature of the heat recovery unit 11 may also be adjusted, without using the reheater 13, by exchange of heat with a component outside the exhaust gas system shown in Fig. 1 .
  • the alkali for example, coal ash
  • SO 3 sulfur trioxide
  • An alkali supplying amount from the alkali supply unit 17 is controlled based on a command from the controller 24 based on a measurement value of at least one among the SO 3 concentration meter 21, the hydrogen chloride concentration meter 22, and the heavy metal concentration meter 23.
  • the mercury adsorbent is added from the mercury adsorbent supply unit 16 in the exhaust gas at the front stage of the electrostatic precipitator 4, the mercury in the exhaust gas is adsorbed by the mercury adsorbent, and the mercury adsorbent that has adsorbed mercury is recovered by the electrostatic precipitator 4.
  • the exhaust gas that has been subject to dust precipitation at the electrostatic precipitator 4 is raised in pressure and introduced by the induction fan 5 into the wet desulfurizer 6, which is based on the spray type limestone-gypsum method and is one example of the desulfurizer, and the SOx in the exhaust gas is removed by gas-liquid contact.
  • the exhaust gas which has been cooled to the saturation gas temperature in the wet desulfurizer 6, is raised in temperature by the reheater 13 and then discharged from the chimney 8 via the desulfurization fan 7.
  • the reheater 13 is a heat exchanger having the heat exchanger tube through which the heating medium flows, and the exhaust gas is raised in temperature, for example, to 90 to 110°C by heat exchange with the heating medium that flows through the heat exchanger tube.
  • the removal efficiency of mercury in the exhaust gas can be improved.
  • control of the exhaust gas temperature by the heating medium flow rate in the heating medium circulating ducts 15-1 and 15-2 may be performed not by control of the heating medium flow rate by the pump 10 but by using one or more among a means that cools the heating medium, a means that heats the heating medium, and a means of adjusting the heating medium flow rate in a bypass tube that is installed so as to shortcut the entrance and the exit of the heating medium duct passing through the heat recovery unit 11.
  • the concentration of the chlorine components (Cl2, HCl) that improve the mercury removal performance is reduced besides the sulfur trioxide (SO 3 ) as shown in Fig. 8 , it is preferable to measure one or two or more component concentrations among the sulfur trioxide concentration, the hydrogen chloride concentration, and the mercury concentration at the exit of the electrostatic precipitator 4 and to spray the alkali according to the measured concentration.
  • the alkali may be mixed in advance with the mercury adsorbent to be added at the rear stage of the heat recovery unit 11, and the alkali may thereby be added from the mercury adsorbent supply unit 16 to prevent a cost increase that accompanies adding of the alkali supply unit 17.
  • the mercury concentration in the recovered ash at the electrostatic precipitator 4 increased significantly, not less than 60% of the mercury in the exhaust gas could be removed, and with the inclusion of the mercury removal by the wet flue gas desulfurizer 6 at the rear stage, not less than 99% of the mercury in the exhaust gas could be removed.
  • the hazardous components in the exhaust gas were monitored continuously by the continuous mercury analyzer, the NOx meter, and the SOx meter and meeting of the regulation values was confirmed.
  • the alkali is accordingly added into the exhaust gas to neutralize and render harmless the sulfuric acid mist, the corrosion of the equipment can be prevented and it was possible to prevent the corrosion of the apparatus even at one year from the start of operation.
  • the exit exhaust gas temperature of the heat recovery unit 11 may also be adjusted, without using the reheater 13, by exchange of heat with a component outside the exhaust gas system shown in Fig. 1 .
  • FIG. 3 is a block diagram of an exhaust gas treating system, with which the mercury adsorbent supply unit 16 of the exhaust gas treating system shown in Fig. 1 is disposed not at the front stage portion of the electrostatic precipitator 4 but at an intermediate position of the electrostatic precipitator 4.
  • the configuration shown in Fig. 3 has the same boiler 1, NOx removal equipment 2, air preheater 3, heat recovery unit 11, induction fan 5, wet desulfurizer 6, reheater 13, desulfurization fan 7, measurement unit 9, chimney 8, pump 10, heating medium circulating ducts 15-1 and 15-2, the mercury adsorbent supply unit 16, thermometer 20 at the heat recovery unit exit, and controller 24 as those of Embodiment 1 and description thereof shall be omitted.
  • control of the exhaust gas temperature by the heating medium flow rate in the heating medium circulating ducts 15-1 and 15-2 may be performed not by control of the heating medium flow rate by the pump 10 but by using one or more among a means that cools the heating medium, a means that heats the heating medium, and a means of adjusting the heating medium flow rate in a bypass tube that is installed so as to shortcut the entrance and the exit of the heating medium duct passing through the heat recovery unit 11.
  • the exit exhaust gas temperature of the heat recovery unit 11 may also be adjusted, without using the reheater 13, by exchange of heat with a component outside the exhaust gas system shown in Fig. 1 .
  • the precipitator 4 has a serial, two-stage structure, and from a front stage section, ash with sulfur trioxide (SO 3 ) attached but with hardly any mercury attached was recovered. Meanwhile, from a second rear stage section, to the rear of the portion at which the mercury adsorbent supply unit 16 is disposed, ash with mercury attached was recovered. With the ash with hardly any mercury attached, effective use as mercury-free ash is possible after removal of the sulfur trioxide (SO 3 ) by rinsing with water, etc.
  • the mercury adsorbent is added to an intermediate position of a single precipitator 4
  • two precipitators 4 may be disposed successively in series in the exhaust gas flow path and the mercury adsorbent supply unit 16 may be disposed between the precipitators to add the mercury adsorbent into the exhaust gas.
  • the sulfur trioxide (SO 3 ) in the exhaust gas is adsorbed to the ash at the exit of the heat recovery unit 11 and the mercury adsorbent is thus added into the exhaust gas in which hardly any sulfur trioxide (SO 3 ) exists, the mercury was adsorbed effectively by the adsorbent, the mercury concentration in the recovered ash was increased significantly, not less than 50% of the mercury in the exhaust gas could be removed, and with the inclusion of the mercury removal at the wet flue gas desulfurizer 6 in the rear stage, not less than 99% of the mercury in the exhaust gas could be removed.
  • An embodiment shown in Fig. 4 is an exhaust gas treating system, with which a configuration for adding the alkali to the exhaust gas treating system shown in Fig. 3 and with which at least one among the SO 3 concentration meter 21, measuring the SO 3 concentration in the exit exhaust gas of the electrostatic precipitator 4, the hydrogen chloride concentration meter 22, measuring the hydrogen chloride (HCl) concentration, and the heavy metal concentration meter 23, measuring the heavy metal concentration, is disposed at the exit of the electrostatic precipitator 4.
  • the boiler 1, the NOx removal equipment 2, the air preheater 3, the electrostatic precipitator 4, the heat recovery unit 11, the induction fan 5, the wet desulfurizer 6, the reheater 13, the desulfurization fan 7, the measurement unit 9, the chimney 8, the pump 10, the heating medium circulating ducts 15-1 and 15-2, the mercury adsorbent supply unit 16, the thermometer 20 at the heat recovery unit exit, and the controller 24 are the same as those of Embodiment 3, and the alkali supply unit 17 is the same as this of Embodiment 2, description thereof shall be omitted.
  • control of the exhaust gas temperature by the heating medium flow rate in the heating medium circulating ducts 15-1 and 15-2 may be performed not by control of the heating medium flow rate by the pump 10 but by using one or more among a means that cools the heating medium, a means that heats the heating medium, and a means of adjusting the heating medium flow rate in a bypass tube that is installed so as to shortcut the entrance and the exit of the heating medium duct passing through the heat recovery unit 11.
  • the exit exhaust gas temperature of the heat recovery unit 11 may also be adjusted, without using the reheater 13, by exchange of heat with a component outside the exhaust gas system shown in Fig. 1 .
  • the controller 24 determines the heating medium circulation amount of the heating medium pump 10, etc., for controlling the exit exhaust gas temperature of the heat recovery unit 11 based on the measurement result of the exhaust gas thermometer 20 that measures the exit exhaust gas temperature of the heat recovery unit 11, and the controller 24 performs control to supply the mercury adsorbent in the exhaust gas from the mercury adsorbent supply unit 16 when the exhaust gas temperature at the exit of the heat recovery unit 11 becomes not more than the condensation temperature of sulfur trioxide (SO 3 ) .
  • SO 3 sulfur trioxide
  • the alkali for example, coal ash
  • SO 3 sulfur trioxide
  • the alkali supply amount from the alkali supply unit 17 is controlled based on the command from the controller 24 based on the measurement value of at least one among the SO 3 concentration meter 21, the hydrogen chloride concentration meter 22, and the heavy metal concentration meter 23 that measures the heavy metal concentration.
  • the alkali may be mixed in advance with the mercury adsorbent to be added at the rear stage of the heat recovery unit 11, and the alkali may be added from the mercury adsorbent supply unit 16 to prevent a cost increase that accompanies the adding of the alkali supply unit 17.
  • Fig. 10 shows a block diagram of Embodiment 5, with which the exit exhaust gas temperature of the heat recovery unit 11 is adjusted, without using the reheater 13 of the exhaust gas treating system shown in Fig. 1 , by exchange of heat with a component outside the exhaust gas system.
  • the boiler 1, the NOx removal equipment 2, the air preheater 3, the electrostatic precipitator 4, the heat recovery unit 11, the induction fan 5, the wet desulfurizer 6, the desulfurization fan 7, the measurement unit 9, the chimney 8, the mercury adsorbent supply unit 16, the thermometer 20 at the heat recovery unit exit, and the controller 24 are the same as those of Embodiment 1 and description thereof shall be omitted.
  • the heating medium that recovers heat from the exhaust gas at the heat recovery unit 11 is introduced by the heating medium circulating duct 15-1 into a feed-water heater (a heating medium cooler) 25 and after performing feed-water heating of the boiler, the heating medium is introduced again into the heat recovery unit 11 by the heating medium circulating duct 15-2.
  • the heating medium is circulated between the heat recovery unit 11 and feed-water heater 25 by the pump 10.
  • the exhaust gas thermometer 20 is disposed to measure the exit exhaust gas temperature of the heat recovery unit 11.
  • the controller 24 is installed to determine the amount of the heating medium circulated by the heating medium pump 10, etc., to control the exit exhaust gas temperature of the heat recovery unit 11 based on the measurement result of the exhaust gas thermometer 20.
  • the control of the exhaust gas temperature by the heating medium flow rate may also be performed by using a means that cools the heating medium, by using a means that heats the heating medium, and by installing a bypass tube 26 that shortcuts an entrance and an exit of the heating medium circulating ducts 15-1 and 15-2 passing through the heat recovery unit 11 and using a heating medium flow control valve 27 for adjusting the heating medium flow rate inside the bypass tube 26.
  • the configuration, shown in Fig. 2 having the alkali supply unit 17 and having at least one among the SO 3 concentration meter 21, measuring the SO 3 concentration in the exit exhaust gas of the dry electrostatic precipitator 4, the hydrogen chloride concentration meter 22, measuring the hydrogen chloride concentration, and the heavy metal concentration meter 23, measuring the heavy metal concentration, disposed at the exit of the electrostatic precipitator 4, or the configuration, shown in Fig. 3 , having the mercury adsorbent supply unit 16 disposed at the intermediate position of the dry electrostatic precipitator 4, or the configuration, shown in Fig. 4 , that combines the configurations shown in Figs. 2 and 3 may be adopted.
  • the sulfur trioxide (SO 3 ) in the exhaust gas is adsorbed to the ash at the exit of the heat recovery unit 11 and the mercury adsorbent is thus added into the exhaust gas in which hardly any sulfur trioxide (SO 3 ) exists, the mercury was adsorbed effectively by the adsorbent, the mercury concentration in the recovered ash was increased significantly, not less than 50% of the mercury in the exhaust gas could be removed, and with the inclusion of the removal of mercury at the wet flue gas desulfurizer 6 in the rear stage, not less than 99% of the mercury in the exhaust gas could be removed. Also with the present system, because the boiler feed-water is heated, a contribution can be made to improving the efficiency of the boiler as well.
  • the concentrations of mercury and other heavy metals in the exhaust gas discharged from a chimney can be reduced. Because the sulfuric acid mist is neutralized and rendered harmless by the coal ash that is high in alkalinity, the corrosion of the equipment can be prevented.
  • the present invention thus has applicability not only to environmental fields but to industry and various other technical fields as an art of effectively reducing heavy metals emitted by combustion.
  • combustion apparatus NOx removal equipment 3 air preheater 4 dry electrostatic precipitator 5 induction fan 6 wet flue gas desulfurizer 7 boost-up fan 8 chimney 9 measurement unit 10 pump 11 heat recovery unit 13 reheater 15 heating medium circulating duct 16 mercury adsorbent supply unit 17 alkali supply unit 20 thermometer 21 SO 3 concentration meter 22 hydrogen chloride concentration meter 23 heavy metal concentration meter 24 controller 25 feed-water heater 26 bypass line 27 heating medium flow control valve 28 boiler feed-water line thermometer

Claims (9)

  1. Abgasbehandlungsverfahren, das die Schritte umfasst:
    Vorwärmen einer Verbrennungsluft einer Verbrennungsvorrichtung (1) durch ein von der Verbrennungsvorrichtung (1) abgegebenes Abgas;
    Rückgewinnen von Wärme aus dem Abgas durch eine Wärmerückgewinnungseinheit (11) nach der Luftvorwärmung; und
    Rückgewinnen von Ruß/Staub in dem Abgas an einem Ausgang der Wärmerückgewinnungseinheit (11) durch einen Trockenabscheider (4); dadurch gekennzeichnet, dass
    nach Einstellen einer Abgastemperatur am Ausgang der Wärmerückgewinnungseinheit (11) auf nicht mehr als eine Taupunkttemperatur von Schwefeltrioxid,
    ein Schwermetall-Adsorptionsmittel in das Abgas an einem Eingang des Trockenabscheiders (4) oder in eine Zwischenposition innerhalb des Trockenabscheiders (4) eingebracht wird, und
    wobei die Wärme des Abgases in einem Heizmedium in der Wärmerückgewinnungseinheit (11) zurückgewonnen wird, das Heizmedium zirkulierend einem Nacherwärmer (13), der zum Erhitzen des entschwefelten Abgases durch das von der Wärmerückgewinnungseinheit (11) zugeführte Heizmedium angeordnet ist, oder einem Kühler (25), der zum Kühlen des von der Wärmerückgewinnungseinheit (11) zugeführten Heizmediums angeordnet ist, zugeführt wird, und
    nach Einstellen der Abgastemperatur am Ausgang der Wärmerückgewinnungseinheit (11) auf nicht mehr als die Taupunkttemperatur von Schwefeltrioxid durch zumindest eines aus einer Zirkulationsmenge des zirkulierenden Heizmediums, zwischen der Wärmerückgewinnungseinheit (11) und dem Nacherwärmer (13), einer Heizmenge des Heizmediums und einer Kühlmenge des Heizmediums ausgewählte Zirkulationsmenge des Heizmediums wird das Schwermetall-Adsorptionsmittel am Eingang des Trockenabscheiders (4) oder in die Zwischenposition innerhalb des Trockenabscheiders (4) in das Abgas eingebracht.
  2. Abgasbehandlungsverfahren nach Anspruch 1, wobei ein Stickoxid in dem Abgas vor der Luftvorwärmung durch einen Denitrierungskatalysator denitriert wird und
    ein Schwefeloxid in dem Abgas am Ausgang des Trockenabscheiders (4) entschwefelt wird.
  3. Abgasbehandlungsverfahren nach Anspruch 1, wobei das Schwermetall-Adsorptionsmittel 0,1 Sekunden nach dem Einstellen der Abgastemperatur am Ausgang der Wärmerückgewinnungseinheit (11) auf nicht mehr als die Taupunkttemperatur von Schwefeltrioxid am Eingang des Trockenabscheiders (4) in das Abgas eingebracht wird.
  4. Abgasbehandlungsverfahren nach Anspruch 1, bei dem ein Alkali an einem Eingang oder Ausgang der Wärmerückgewinnungseinheit (11) in das Abgas gesprüht wird und das Schwermetall-Adsorptionsmittel nach Einstellen der Abgastemperatur am Ausgang der Wärmerückgewinnungseinheit (11) auf nicht mehr als die Taupunkttemperatur von Schwefeltrioxid eingebracht wird.
  5. Abgasbehandlungsverfahren nach Anspruch 4, bei dem zumindest eines aus einer Schwefeltrioxidkonzentration, einer Chlorkonzentration und einer Schwermetallkonzentration in dem Abgas am Ausgang des Trockenabscheiders (4) gemessen wird und eine Menge des Alkalis, die der gemessenen Konzentration entspricht, dem Abgas am Eingang der Wärmerückgewinnungseinheit (11) oder am Ausgang der Wärmerückgewinnungseinheit (11) zugeführt wird.
  6. Abgasbehandlungsvorrichtung, die umfasst: einen Luftvorwärmer (3), der eine Verbrennungsluft der Verbrennungsvorrichtung (1) durch ein von der Verbrennungsvorrichtung (1) abgegebenes Abgas vorwärmt; eine Wärmerückgewinnungseinheit (11), die Wärme aus dem Abgas an einem Ausgang des Luftvorwärmers (3) zurückgewinnt; und einen Trockenabscheider (4), der Ruß/Staub in dem Abgas an einem Ausgang der Wärmerückgewinnungseinheit (11) zurückgewinnt, die aufeinanderfolgend von einer stromaufwärtigen Seite zu einer stromabwärtigen Seite einer Abgasleitung einer Verbrennungsvorrichtung (1) angeordnet sind; dadurch gekennzeichnet, dass sie ferner umfasst;
    eine Steuerung (24), die eine Abgastemperatur am Ausgang der Wärmerückgewinnungseinheit (11) auf nicht mehr als eine Taupunkttemperatur von Schwefeltrioxid steuert; und
    eine Schwermetall-Adsorptionsmittel-Zufuhreinheit (16), die ein Schwermetall-Adsorptionsmittel in das Abgas an einem Eingang des Trockenabscheiders (4) oder in eine Zwischenposition innerhalb des Trockenabscheiders (4) einbringt, und
    wobei die Wärmerückgewinnungseinheit (11) einen Satz von Wärmetauscherrohren umfasst, die die Wärme des Abgases in ein Heizmedium zurückgewinnen, und die Abgasbehandlungsvorrichtung ferner umfasst:
    einen Nacherwärmer (13), der wiederum einen Satz von Wärmetauscherrohren umfasst, die das Abgas an einem Ausgang des Entschwefelers (6) durch das von der Wärmerückgewinnungseinheit (11) zugeführte Heizmedium erwärmen, oder einen Kühler (25), der wiederum einen Satz von Wärmetauscherrohren umfasst, die das von der Wärmerückgewinnungseinheit (11) zugeführte Heizmedium kühlen;
    eine Zirkulationsleitung (15), die die Wärmetauscherrohre, die jeweils in der Wärmerückgewinnungseinheit (11) und dem Nacherwärmer (13) angeordnet sind, oder die Wärmetauscherrohre, die jeweils in der Wärmerückgewinnungseinheit (11) und den Kühler (25) angeordnet sind, miteinander verbindet, um das Heizmedium im Inneren der Wärmetauscherrohre zirkulieren zu lassen; und
    eine Einstelleinheit (10), die mittels der Steuerung (24) zumindest eines aus einer Zirkulationsmenge des durch die Zirkulationsleitung (15) fließenden Heizmediums, einer Heizmedium-Heizmenge und einer Heizmedium-Kühlmenge einstellt.
  7. Abgasbehandlungsvorrichtung nach Anspruch 6, die ferner eine NOx-Entfernungseinrichtung (2), die ihrerseits einen Denitrierungskatalysator umfasst, der das Abgas an einem Eingang des Luftvorwärmers (3) denitriert; und
    einen Entschwefeler (6) umfasst, der das Abgas am Ausgang des Trockenabscheiders (4) entschwefelt.
  8. Abgasbehandlungsvorrichtung nach Anspruch 6, die ferner eine Alkalizufuhreinheit (17), die dem Abgas am Eingang der Wärmerückgewinnungseinheit (11) oder am Ausgang der Wärmerückgewinnungseinheit (11) ein Alkali zuführt, umfasst.
  9. Abgasbehandlungsvorrichtung nach Anspruch 8, die dadurch gekennzeichnet ist, dass sie ferner umfasst;
    eine Schwermetall-Adsorptionsmittel-Zufuhreinheit (16), die ein Schwermetall-Adsorptionsmittel in das Abgas am Eingang des Trockenabscheiders (4) oder in eine Zwischenposition innerhalb des Trockenabscheiders (4) einbringt, und
    eine Alkalizufuhreinheit (17), die am Eingang der Wärmerückgewinnungseinheit (11) oder am Ausgang der Wärmerückgewinnungseinheit (11) ein Alkali in das Abgas zuführt, und
    eine Messeinheit (21-23), die zumindest eines aus einer Schwefeltrioxidkonzentration, einer Chlorkonzentration und einer Schwermetallkonzentration in dem Abgas am Ausgang des Trockenabscheiders (4) misst; und
    eine Einstelleinheit (10), die mittels der Steuerung (24) eine Menge des von der Alkalizufuhreinheit (17) am Eingang der Wärmerückgewinnungseinheit (11) oder am Ausgang der Wärmerückgewinnungseinheit (11) in das Abgas zugeführten Alkalis entsprechend den Messwerten der Messeinheit (21-23) einstellt.
EP07859994.1A 2006-12-27 2007-12-24 Abgasbehandlungsverfahren und vorrichtung Active EP2103339B8 (de)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PL07859994T PL2103339T3 (pl) 2006-12-27 2007-12-24 Sposób i urządzenie do oczyszczania gazów spalinowych

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
JP2006353270 2006-12-27
PCT/JP2007/074765 WO2008078721A1 (ja) 2006-12-27 2007-12-24 排ガス処理方法と装置

Publications (4)

Publication Number Publication Date
EP2103339A1 EP2103339A1 (de) 2009-09-23
EP2103339A4 EP2103339A4 (de) 2017-05-17
EP2103339B1 true EP2103339B1 (de) 2020-11-25
EP2103339B8 EP2103339B8 (de) 2021-01-20

Family

ID=39562510

Family Applications (1)

Application Number Title Priority Date Filing Date
EP07859994.1A Active EP2103339B8 (de) 2006-12-27 2007-12-24 Abgasbehandlungsverfahren und vorrichtung

Country Status (6)

Country Link
US (1) US8302388B2 (de)
EP (1) EP2103339B8 (de)
JP (1) JP5180097B2 (de)
CA (1) CA2672577C (de)
PL (1) PL2103339T3 (de)
WO (1) WO2008078721A1 (de)

Families Citing this family (47)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN101511446B (zh) * 2006-07-26 2012-05-02 巴布考克日立株式会社 排气中微量有害物质的除去装置和其运行方法
JP5198786B2 (ja) * 2007-04-13 2013-05-15 バブコック日立株式会社 排ガス浄化方法と装置
JP5113788B2 (ja) * 2009-03-19 2013-01-09 バブコック日立株式会社 排ガス処理システム
JP5350996B2 (ja) * 2009-11-25 2013-11-27 バブコック日立株式会社 酸素燃焼システムの排ガス処理装置
US20110269079A1 (en) * 2010-04-28 2011-11-03 Enviromental Energy Services, Inc. Process for operating a utility boiler and methods therefor
US8444941B2 (en) 2010-05-25 2013-05-21 Intercat Equipment, Inc. Cracking catalysts, additives, methods of making them and using them
CA2801000C (en) 2010-05-31 2015-12-01 Mitsubishi Heavy Industries, Ltd. Air pollution control system and method
US8871164B2 (en) 2010-05-31 2014-10-28 Mitsubushi Heavy Industries, Ltd. Air pollution control system and method
WO2011152551A1 (ja) * 2010-05-31 2011-12-08 三菱重工業株式会社 排ガス処理システム及び方法
EP2578295B1 (de) 2010-05-31 2020-05-27 Mitsubishi Heavy Industries Engineering, Ltd. Abgasverarbeitungssystem und -verfahren
WO2011152547A1 (ja) 2010-05-31 2011-12-08 三菱重工業株式会社 排ガス処理システム及び方法
US8894941B2 (en) 2010-05-31 2014-11-25 Mitsubishi Heavy Industries, Ltd. Air pollution control system and method
US20110308436A1 (en) * 2010-06-21 2011-12-22 Air Products And Chemicals, Inc. System and Method for Improved Heat Recovery from Flue Gases with High SO3 Concentrations
CN201819234U (zh) * 2010-09-21 2011-05-04 上海伏波环保设备有限公司 节能型除尘器
US8882884B2 (en) * 2010-09-29 2014-11-11 Southern Company Systems and methods for optimizing a PAC ratio
US8147587B2 (en) * 2011-04-15 2012-04-03 Bha Group, Inc. Enhanced mercury capture from coal-fired power plants in the filtration baghouse using flue gas temperature as process control knob
DE102012102943A1 (de) * 2012-04-04 2013-10-10 Benteler Automobiltechnik Gmbh Wärmetauscheranordnung sowie Verfahren zum Betreiben einer Verbrennungseinrichtung
US8591844B1 (en) * 2012-05-17 2013-11-26 Fluor Technologies Corporation Start up catalyst heating
US9289720B2 (en) 2012-05-31 2016-03-22 Mitsubishi Hitachi Power Systems, Ltd. System and method for treating mercury in flue gas
US8734747B2 (en) * 2012-09-20 2014-05-27 Mitsubishi Heavy Industries, Ltd. Method and apparatus for treating exhaust gas
JP5966804B2 (ja) * 2012-09-21 2016-08-10 三菱重工冷熱株式会社 除塵減臭システムおよび除塵減臭方法
JP2014094352A (ja) * 2012-11-09 2014-05-22 Mitsubishi Heavy Ind Ltd 排ガス処理装置及び方法
BE1021414B1 (nl) * 2012-11-23 2015-11-18 Nantong Tianlan Environmental Protection Energy Equipment Co., LTD Uitlaatgasbehandelingsinrichting en werkwijze voor het koelen en neutraliseren van uitlaatgas van een verbrandingsinrichting
JP5624646B1 (ja) 2013-05-23 2014-11-12 電源開発株式会社 火力発電プラント及び火力発電プラントの運転方法。
US9181888B2 (en) 2013-10-28 2015-11-10 Cummins Inc. Selectively trapping and storing SO3 in an exhaust gas effluent
CN103604133B (zh) * 2013-11-05 2015-10-07 西安热工研究院有限公司 一种多污染物一体化干法脱除的烟气净化系统及工艺
JP6212401B2 (ja) 2014-01-31 2017-10-11 三菱日立パワーシステムズ株式会社 排ガス処理装置
JP6254012B2 (ja) 2014-02-24 2017-12-27 三菱日立パワーシステムズ株式会社 排ガス処理システム及び排ガス処理方法
JP6632198B2 (ja) * 2015-02-05 2020-01-22 三菱日立パワーシステムズ株式会社 熱交換器及び熱交換器の制御方法
CN104832945A (zh) * 2015-05-05 2015-08-12 中国能源建设集团广东省电力设计研究院有限公司 烟气余热利用系统
JP6637682B2 (ja) * 2015-06-18 2020-01-29 三菱日立パワーシステムズ株式会社 石炭焚ボイラ用排ガス処理装置と石炭焚ボイラ用排ガス処理方法
CN105351955A (zh) * 2015-11-05 2016-02-24 武汉烽火兴业节能环保科技有限公司 一种烟气除尘智能检测系统及方法
GB2566911A (en) * 2016-07-08 2019-03-27 Arvos Ljungstrom Llc Method and system for improving boiler effectiveness
US10267517B2 (en) * 2016-07-08 2019-04-23 Arvos Ljungstrom Llc Method and system for improving boiler effectiveness
US10478775B2 (en) * 2016-08-01 2019-11-19 The Babcock & Wilcox Company Metal capture in a flue gas using sorbent injection
JP6749209B2 (ja) * 2016-10-21 2020-09-02 日立造船株式会社 薬剤投入装置および燃焼排ガスの処理設備
US10821466B2 (en) * 2017-07-06 2020-11-03 Nordson Corporation Systems and methods for solvent extraction
JP6909667B2 (ja) * 2017-07-31 2021-07-28 日立造船株式会社 燃焼排ガスの処理装置
JP2019027672A (ja) * 2017-07-31 2019-02-21 日立造船株式会社 燃焼排ガスの処理装置
JP7106357B2 (ja) * 2018-06-06 2022-07-26 日立造船株式会社 排ガス処理装置
CN108744896B (zh) * 2018-07-20 2023-12-15 四川思达能环保科技有限公司 一种氮氧化物烟气吸收制酸系统
CA3102921A1 (en) * 2018-09-14 2020-03-19 Minplus B.V. A method of operating an incinerator comprising a device for capturing ash entrained by flue gas
JP6775047B2 (ja) * 2019-02-25 2020-10-28 月島機械株式会社 白煙防止システム、焼却設備および白煙防止方法
CN110523250A (zh) * 2019-09-23 2019-12-03 华北电力大学（保定） 一种可有效降低重金属含量的移动源尾气后处理系统
JP7356345B2 (ja) * 2019-12-27 2023-10-04 三菱重工業株式会社 排気ガス処理設備、及びガスタービンプラント
CN111420550A (zh) * 2020-04-01 2020-07-17 湖南萃智咨询服务有限公司 一种水泥窑窑尾烟气催化氧化脱硫方法
CN113483329A (zh) * 2021-07-08 2021-10-08 陕西青朗万城环保科技有限公司 一种固废燃烧处理方法及其控制系统

Family Cites Families (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
AT380092B (de) * 1983-09-29 1986-04-10 Simmering Graz Pauker Ag Verfahren und vorrichtung zur gewinnung von waerme aus wasserdampfhaeltigen gasen durch absorption oder adsorption
DE3424196A1 (de) * 1984-02-11 1985-08-22 Robert Bosch Gmbh, 7000 Stuttgart Einrichtung zur entfernung von festkoerperteilen aus abgasen von brennkraftmaschinen
US4969328A (en) * 1986-10-21 1990-11-13 Kammel Refaat A Diesel engine exhaust oxidizer
US5125230A (en) * 1987-10-09 1992-06-30 Kerr-Mcgee Coal Corporation Soot removal from exhaust gas
JP3544432B2 (ja) * 1996-06-07 2004-07-21 バブコック日立株式会社 排煙処理装置とその運用方法
JP2000015057A (ja) * 1998-07-01 2000-01-18 Sumitomo Heavy Ind Ltd 焼却炉の排ガス処理装置及び方法
JP3698916B2 (ja) 1999-05-19 2005-09-21 バブコック日立株式会社 石炭類の燃焼排ガス中の水銀除去方法および装置
US7585352B2 (en) * 2002-08-21 2009-09-08 Dunn John P Grid electrostatic precipitator/filter for diesel engine exhaust removal
US7651389B2 (en) * 2002-09-09 2010-01-26 Babcock-Hitachi Kabushiki Kaisha Exhaust smoke-processing system
CN100429460C (zh) * 2002-11-05 2008-10-29 巴布考克日立株式会社 废气处理装置
JP4761284B2 (ja) * 2002-11-06 2011-08-31 バブコック日立株式会社 排ガス処理装置とその運用方法
US20050201914A1 (en) * 2004-03-12 2005-09-15 American Electric Power Company, Inc. System and method for treating a flue gas stream
US7302795B2 (en) * 2005-07-11 2007-12-04 Jan Vetrovec Internal combustion engine/water source system
JP4845568B2 (ja) * 2006-04-04 2011-12-28 バブコック日立株式会社 湿式排煙脱硫装置

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
None *

Also Published As

Publication number Publication date
EP2103339A4 (de) 2017-05-17
US20100071348A1 (en) 2010-03-25
CA2672577C (en) 2014-08-05
CA2672577A1 (en) 2008-07-03
JP5180097B2 (ja) 2013-04-10
JPWO2008078721A1 (ja) 2010-04-22
EP2103339A1 (de) 2009-09-23
EP2103339B8 (de) 2021-01-20
WO2008078721A1 (ja) 2008-07-03
PL2103339T3 (pl) 2021-05-31
US8302388B2 (en) 2012-11-06

Similar Documents

Publication Publication Date Title
EP2103339B1 (de) Abgasbehandlungsverfahren und vorrichtung
EP2127728B1 (de) Verfahren und vorrichtung zur behandlung von abgas
US7572420B2 (en) Method for removing mercury in exhaust gas and system therefor
US8167975B2 (en) Exhaust gas purifying method and apparatus
US9289720B2 (en) System and method for treating mercury in flue gas
WO2011064975A1 (ja) 酸素燃焼システムの排ガス処理装置
US10247414B2 (en) Coal-fired boiler exhaust gas treatment apparatus and coal-fired boiler exhaust gas treatment method
JP2010516464A (ja) アンモニアの酸洗浄における煙道ガスからのｓｏ２の使用
PL204639B1 (pl) Sposób usuwania rtęci z gazów spalinowych
TW200406251A (en) Exhaust smoke-processing system
JP2007245074A (ja) 排ガス処理装置
WO2011142376A1 (ja) 二酸化炭素化学吸収設備を有する排ガス処理システム
WO1998048924A1 (fr) Procede de traitement des emanations gazeuses
JP4936002B2 (ja) 排ガス処理方法及び排ガス処理装置
JP2014091058A (ja) 排ガス処理装置と排ガス処理方法
JP3383051B2 (ja) 排ガスの浄化処理方法およびその装置
JP2013034965A (ja) 湿式排煙処理装置と方法
JP5299600B2 (ja) 排ガス処理方法及び排ガス処理装置
WO2012026114A1 (ja) 排ガス処理装置
WO2012029279A1 (ja) 排ガス処理装置

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

17P Request for examination filed

Effective date: 20090610

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IS IT LI LT LU LV MC MT NL PL PT RO SE SI SK TR

DAX Request for extension of the european patent (deleted)
RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: MITSUBISHI HITACHI POWER SYSTEMS, LTD.

RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: MITSUBISHI HITACHI POWER SYSTEMS, LTD.

RA4 Supplementary search report drawn up and despatched (corrected)

Effective date: 20170413

RIC1 Information provided on ipc code assigned before grant

Ipc: B01D 53/68 20060101ALI20170408BHEP

Ipc: B01D 53/10 20060101ALI20170408BHEP

Ipc: B01D 53/94 20060101ALI20170408BHEP

Ipc: F23J 15/00 20060101ALI20170408BHEP

Ipc: B01D 53/86 20060101ALI20170408BHEP

Ipc: B01D 53/50 20060101ALI20170408BHEP

Ipc: F23J 15/02 20060101ALI20170408BHEP

Ipc: B01D 53/77 20060101ALI20170408BHEP

Ipc: B01D 53/64 20060101AFI20170408BHEP

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

RIC1 Information provided on ipc code assigned before grant

Ipc: B01D 53/10 20060101ALI20200518BHEP

Ipc: F23J 15/02 20060101ALI20200518BHEP

Ipc: B01D 53/86 20060101ALI20200518BHEP

Ipc: B01D 53/68 20060101ALI20200518BHEP

Ipc: B01D 53/77 20060101ALI20200518BHEP

Ipc: B01D 53/94 20060101ALI20200518BHEP

Ipc: F23J 15/00 20060101ALI20200518BHEP

Ipc: B01D 53/64 20060101AFI20200518BHEP

Ipc: B01D 53/50 20060101ALI20200518BHEP

INTG Intention to grant announced

Effective date: 20200612

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IS IT LI LT LU LV MC MT NL PL PT RO SE SI SK TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602007060803

Country of ref document: DE

REG Reference to a national code

Ref country code: AT

Ref legal event code: REF

Ref document number: 1337643

Country of ref document: AT

Kind code of ref document: T

Effective date: 20201215

RAP2 Party data changed (patent owner data changed or rights of a patent transferred)

Owner name: MITSUBISHI POWER, LTD.

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 1337643

Country of ref document: AT

Kind code of ref document: T

Effective date: 20201125

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20201125

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210325

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210226

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210325

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210225

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG9D

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602007060803

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: MC

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

REG Reference to a national code

Ref country code: BE

Ref legal event code: MM

Effective date: 20201231

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20210225

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20201224

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210125

Ref country code: IT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: IE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20201224

26N No opposition filed

Effective date: 20210826

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20201231

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210701

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20201231

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210225

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: PL

Payment date: 20211117

Year of fee payment: 15

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210325

Ref country code: TR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: MT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201125

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20201231